Yoho Resources Inc. Announces Year End Financial Results and Pro-Forma Reserves Information as at September 30, 2015

CALGARY, ALBERTA–(Marketwired – Jan. 14, 2016) – Yoho Resources Inc. (TSX VENTURE:YO) (“Yoho” or the “Company”) has filed today on SEDAR the financial statements for the year ended September 30, 2015 and the related managements’ discussion and analysis (“MD&A”). Copies of these documents may be found on www.sedar.com.

In December 2015, subsequent to its 2015 fiscal year end, Yoho closed a transaction to sell a portion of its Duvernay assets in the Kaybob area of Alberta for cash consideration of $50 million (prior to adjustments) (the “Transaction”). Yoho has retained approximately 25% of its net Kaybob Duvernay acreage consisting of 5.5 sections at 100% working interest and the Company’s recently completed Duvernay horizontal well at 16-12-59-19 W5.

Highlights

Yoho’s production during fiscal 2015 averaged 1,714 boe per day (34% oil and natural gas liquids (“NGL”)), compared to fiscal 2014 production of 1,712 boe per day (29% oil and NGL).

Yoho generated funds from operations for fiscal 2015 of $4.6 million ($0.08 per share basic).

Net exploration and development expenditures for fiscal 2015 were $31.6 million primarily for drilling and completions, including the drilling of 3 (1.0 net) wells.

Due to the ongoing low price commodity environment, the Company has recorded an impairment of $77.1 million on its property, plant and equipment during fiscal 2015, resulting in a net loss of $62.6 million for fiscal 2015.

Subsequent to the Transaction, Yoho’s proved plus probable reserves (Company interest) as evaluated by GLJ as at September 30, 2015 were 13.2 MMboe and the Company’s proved reserves (Company interest) as at September 30, 2015 were 5.9 MMboe.

Year ended
September 30,
2015

Year ended
September 30,
2014

Financial ($)

Petroleum and natural gas sales

16,529,720

26,234,952

Funds from operations (1)

4,581,133

11,135,762

per share – basic

0.08

0.22

per share – diluted

0.08

0.21

Net income (loss)

(62,563,607)

43,154,230

per share – basic

(1.13)

0.83

per share – diluted

(1.13)

0.82

Net exploration and development expenditures

34,539,821

31,721,969

Net acquisitions and dispositions

(2,969,455)

(30,194,887)

Total assets

112,180,973

164,812,494

Total debt (including working capital deficiency)

27,977,846

16,225,061

Shareholders’ equity

59,640,259

114,110,071

Weighted average common shares outstanding

Basic

55,137,918

51,703,235

Diluted

55,137,918

52,708,183

Year ended
September 30,
2015

Year ended
September 30,
2014

Operations

Production

Natural gas (mcf/d)

6,762

7,292

Oil and NGL (bbls/d)

587

497

Combined (boe/d)

1,714

1,712

Realized sales prices

Natural gas ($/mcf)

2.56

4.47

Oil and NGL ($/bbl)

47.69

78.96

Funds from operations per boe ($/boe)

Petroleum and natural gas sales

26.42

41.97

Royalties

(1.22)

(4.26)

Operating expenses

(12.95)

(12.59)

Operating netback (2)

12.25

25.12

General and administrative

(3.25)

(4.74)

Interest

(1.76)

(1.05)

Realized gain (loss) on financial derivative contracts

0.07

(1.51)

Funds from operations (1)

7.31

17.82

Drilling activity

Total wells

3

7

Working interest wells

1.0

4.3

Undeveloped land (net acres)

69,232

89,755

Notes:

(1) Funds from operations is calculated as cash provided by operating activities, adding the change in non-cash working capital and decommissioning obligation expenditures. Funds from operations is used to analyze the Company’s operating performance and leverage. Funds from operations does not have a standardized measure prescribed by IFRS and therefore may not be comparable with the calculations of similar measures for other companies. Yoho’s calculation of funds from operations is detailed in the MD&A for the years ended September 30, 2015 and 2014.

(2) Operating netback equals petroleum and natural gas sales less royalties, operating costs and transportation costs calculated on a boe basis. Operating netback does not have a standardized measure prescribed by IFRS and therefore may not be comparable with the calculations of similar measures for other companies.

CORPORATE RESERVES POST TRANSACTION

The reserves data set forth below is based upon an independent reserve assessment and evaluation prepared by GLJ with an effective date of September 30, 2015 (the “GLJ Report”) and excludes the reserves related to the Duvernay assets sold in the Transaction. A full summary of the Company’s reserves as at September 30, 2015 (including those that were subject to the Transaction), will be included in the Company’s Annual Information Form for the year ended September 30, 2015, which will be available shortly on SEDAR at www.sedar.com. The following summarizes the Company’s crude oil, natural gas liquids and natural gas reserves and the net present values before income taxes of future net revenue for the Company’s reserves using forecast prices and costs based on the GLJ Report. The GLJ Report has been prepared in accordance with the standards contained in the Canadian Oil and Gas Evaluation Handbook (the “COGE Handbook”) and the reserve definitions contained in National Instrument 51-101 – Standards of Disclosure for Oil and Gas Activities (“NI 51-101”).

All evaluations and reviews of future net cash flows are stated prior to any provisions for interest costs or general and administrative costs and after the deduction of estimated future capital expenditures for wells to which reserves have been assigned. It should not be assumed that the estimates of future net revenues presented in the tables below represent the fair market value of the reserves. There is no assurance that the forecast prices and cost assumptions will be attained and variances from these assumptions could be material. The recovery and reserve estimates of the crude oil, natural gas liquids and natural gas reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered. Actual crude oil, natural gas and natural gas liquids reserves may be greater than or less than the estimates provided herein.

Reserves Summary Post -Transaction

The following table provides summary reserve information based upon the GLJ Report and using the published GLJ (October 1, 2015) price forecast, after giving effect to the Transaction.

Light and Medium Oil

Heavy Oil

Natural Gas Liquids

Company
Interest (1)

Net (2)

Company
Interest (1)

Net(2)

Company
Interest (1)

Net (2)

(Mbbl)

(Mbbl)

(Mbbl)

(Mbbl)

(Mbbl)

(Mbbl)

Proved

Proved producing

136

120

83

72

141

103

Non-producing

10

10

24

22

375

284

Undeveloped

132

112

–

–

813

675

Total proved

278

242

108

94

1,329

1,062

Probable

215

182

29

24

2,334

1,871

Total proved & probable (4)

493

424

137

118

3,663

2,933

Total Natural Gas

Total Barrels of
Oil Equivalent (3)

Company
Interest (1)

Net (2)

Company
Interest (1)

Net (2)

(Mmcf)

(Mmcf)

(Mboe)

(Mboe)

Proved

Proved producing

8,471

7,933

1,773

1,617

Non-producing

4,799

4,424

1,209

1,053

Undeveloped

11,689

10,942

2,893

2,611

Total proved

24,959

23,299

5,875

5,281

Probable

28,466

26,214

7,322

6,447

Total proved & probable (4)

53,425

49,513

13,197

11,727

Notes:

(1) “Company Interest” reserves means Yoho’s working interest (operating and non-operating) share before deduction of royalties and including any royalty interest of the Company.

(3) Barrels of oil equivalent, or BOE, amounts have been calculated using a conversion rate of six thousand cubic feet of natural gas to one barrel of oil. BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of six thousand cubic feet of natural gas to one barrel of oil is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.

(4) May not add due to rounding.

Reserves Values Post-Transaction

The estimated before tax net present value of future net revenues, after giving effect to the Transaction, associated with Yoho’s reserves effective September 30, 2015 and based on the published GLJ (October 1, 2015) future price forecast are summarized in the following table:

Discounted at

Undiscounted

5%

10%

15%

20%

(M$)

Proved

Proved producing

12,232

10,928

9,384

8,130

7,158

Non-producing

22,267

14,282

10,213

7,780

6,154

Undeveloped

46,069

26,276

16,310

10,691

7,247

Total proved

80,569

51,485

35,907

26,601

20,559

Probable

171,973

87,501

52,276

34,500

24,292

Total proved plus probable(3)

252,542

138,987

88,184

61,100

44,851

Notes:

(1) The estimated future net revenues are reduced for estimated future abandonment and reclamation costs and estimated capital for future development associated with the reserves.

The following table sets forth development costs deducted in the estimation of the future net revenue attributable to the reserve categories noted above, after giving effect to the Transaction.

Development Costs
Forecast Prices and Costs

Proved Reserves

Proved Plus
Probable Reserves

Year

(M$)

(M$)

Q4 2015

13,520

16,820

2016

208

18,404

2017

9,269

9,518

2018

249

4,515

2019

14,429

14,450

2020

88

14,717

Remainder

675

16,170

Total Undiscounted (all years)

38,438

94,594

Total Discounted 10%

31,991

73,734

Price Forecast

The GLJ October 1, 2015 price forecast is summarized as follows:

Calendar Year

2015 Q4

2016

2017

2018

2019

2020

2021

2022

2023

2024

Edmonton ($Cdn/bbl)

56.00

61.33

64.52

68.75

72.73

76.47

82.35

88.24

94.12

98.41

Heavy crude (12°API) at Hardisty ($Cdn/bbl)

36.69

42.30

46.23

50.22

54.13

57.96

63.56

69.32

75.24

78.71

Alberta Plant Gate ($Cdn/mmbtu)

2.74

3.20

3.38

3.48

3.57

3.66

3.86

4.06

4.26

4.53

British Columbia Plant Gate ($Cdn/mmbtu)

1.99

2.84

3.23

3.33

3.42

3.51

3.71

3.91

4.10

4.38

Note:

(1) Inflation is accounted for at 2.0% per year

OUTLOOK

Yoho’s current initial fiscal 2016 plan includes a capital program of $7 to $8 million with average production of 900 to 1,000 boe per day. Completion operations on Yoho’s 100% Duvernay well in Kaybob were finished during fiscal Q1 2016. Operations to equip and tie-in this well are expected to commence in fiscal Q3 2016 with initial production from this well expected in fiscal Q4 2016.

About Yoho

Yoho Resources Inc. is a Calgary based junior oil and natural gas company with operations focusing in West Central Alberta and northeast British Columbia. The common shares of Yoho are listed on the TSX Venture Exchange under the symbol “YO”.

Advisories & Contact

Neither TSX Venture Exchange nor its Regulation Services Provider (as that term is defined in the policies of the TSX Venture Exchange) accepts responsibility for the adequacy or accuracy of this release.

Cautionary Statements

Special Note Regarding Forward-Looking Information

Certain information regarding Yoho set forth in this document, including estimates of the quantities of the Company’s reserves and the matters set forth under the heading “Outlook”, may constitute forward-looking statements under applicable securities laws and necessarily involve substantial known and unknown risks and uncertainties. These forward-looking statements are subject to numerous risks and uncertainties, certain of which are beyond Yoho’s control, including without limitation, risks associated with oil and gas exploration, development, exploitation, production, marketing and transportation, loss of markets, volatility of commodity prices, environmental risks, inability to obtain drilling rigs or other services, capital expenditure costs, including drilling, completion and facility costs, unexpected decline rates in wells, wells not performing as expected, delays resulting from or inability to obtain required regulatory approvals and ability to access sufficient capital from internal and external sources, the impact of general economic conditions in Canada, the United States and overseas, industry conditions, changes in laws and regulations (including the adoption of new environmental laws and regulations) and changes in how they are interpreted and enforced, increased competition, the lack of availability of qualified personnel or management, fluctuations in foreign exchange or interest rates, and the uncertainty of estimates and projections of production, costs and expenses. The recovery and reserve estimates of Yoho’s reserves provided herein are estimates only and there is no guarantee that the estimated reserves will be recovered.

With respect to forward-looking statements contained in this document, Yoho has made a number of assumptions. The key assumptions underlying the aforementioned forward-looking statements include assumptions regarding (among other things): the impact of increasing competition; the general stability of the economic and political environment in which the Company operates; the timely receipt of any required regulatory approvals; the ability of the Company to obtain qualified staff, equipment and services in a timely and cost efficient manner; drilling results; the ability of the operator of the projects which the Company has an interest in operating the field in a safe, efficient and effective manner; the ability of the Company to obtain financing on acceptable terms; field production rates and decline rates; the ability to replace and expand oil and natural gas reserves through acquisition, development of exploration; the timing and costs of pipeline, storage and facility construction and expansion and the ability of the Company to secure adequate product transportation; future commodity prices; currency, exchange and interest rates; the regulatory framework regarding royalties, taxes and environmental matters in the jurisdictions in which the Company operates; and the ability of the Company to successfully market its oil and natural gas production. Certain or all of the forgoing assumptions may prove to be untrue.

Yoho’s actual results, performance or achievement could differ materially from those expressed in, or implied by, these forward-looking statements and, accordingly, no assurance can be given that any of the events anticipated by the forward-looking statements will transpire or occur, or if any of them do so, what benefits, that the Company will derive therefrom. All subsequent forward-looking statements, whether written or oral, attributable to the Company or persons acting on its behalf are expressly qualified in their entirety by these cautionary statements. Additional information on these and other factors that could affect Yoho’s operations and financial results are included in reports on file with Canadian securities regulatory authorities and may be accessed through the SEDAR website (www.sedar.com) or Yoho’s website (www.yohoresources.ca).

The forward-looking statements contained in this document are made as at the date of this news release and Yoho does not undertake any obligation to update publicly or to revise any of the included forward-looking statements, whether as a result of new information, future events or otherwise, except as may be required by applicable securities laws.

BOE Equivalency

Barrel of oil equivalents or BOEs may be misleading, particularly if used in isolation. A BOE conversion ratio of 6 Mcf: 1 bbl is based on an energy equivalency conversion method primarily applicable at the burner tip and does not represent a value equivalency at the wellhead. Given the value ratio based on the current price of crude oil as compared to natural gas is significantly different from the energy equivalency of 6 mcf: 1 bbl, utilizing a conversion ratio of 6 mcf: 1 bbl may be a misleading indication of value.

Oil and Gas Advisory

The reserves information contained in this press release has been prepared in accordance with NI 51-101. Listed below are cautionary statements applicable to our reserves information that are specifically required by NI 51-101:

Individual properties may not reflect the same confidence level as estimates of reserves for all properties due to the effects of aggregation.

With respect to finding and development costs, the aggregate of the exploration and development costs incurred in the most recent financial year and the change during that year in estimated future development costs generally will not reflect total finding and development costs related to reserve additions for that year.

This press release contains estimates of the net present value of our future net revenue from our reserves. Such amounts do not represent the fair market value of our reserves.

Reserves included herein are stated on a company interest basis (before royalty burdens and including royalty interests) unless noted otherwise as well as on a gross and net basis as defined in NI 51-101. “Company interest” is not a term defined by NI 51-101 and as such the estimates of Company interest reserves herein may not be comparable to estimates of “gross” reserves prepared in accordance with NI 51-101 or to other issuers’ estimates of company interest reserves.

Selected Definitions

The following terms used in this press release have the meanings set forth below:

“API” means American Petroleum Institute

“bbl”means barrel

“boe” means barrel of oil equivalent of natural gas and crude oil on the basis of 1 boe for six thousand cubic feet of natural gas (this conversion factor is and industry accepted norm and is not based on either energy content or current prices)